Subsurface well tool



y 3, 1954 R. c. BAKER 2,683,492

SUBSURFACE WELL TOOL Original Filed July 10,- 1950 3 Sheets-Sheet 2INVEVTOR. REUBEN 6. BAKER,

A rraezvsxf y 1954 R. c. BAKER 2,683,492

SUBSURFACE WELL TOOL Original Filed July 10, 1950 3 Sheets-Sheet 3 INVEN TOR.

REUB N C. BAKEQ,

Ar ram/5Y5 Patented July 13, 1954 UITED STAT TENT OFFICE SUBSURFACE WELLTOOL Reuben C. Baker, Coalinga, Calif., assignor to Baker Gil Tools,Inc., Vernon, Calif., a corporation of California 11 Claims.

initially retracted well tool slip segments between their retracted andexpanded positions.

Yet a further object of the invention is to provide a slip arrangementfor a well tool that insures maintenance of the slips in retractedposition while the tool is being run in the well bore,

and which resists premature outward expansion of the slips.

lhis invention possesses many other advan tages, and has other objectswhich may be made more clearly apparent from a consideration of a formin which it may be embodied. This form is shown in the drawingsaccompanying and forming part of the present specification. It will nowbe described in detail, for the purpose of illustrating the generalprinciples of the invention; but it is to be understood that suchdetailed description is not to be taken in a limiting sense, since thescope of the invention is best defined by the appended claims.

Referring to the drawings:

Figures 1a lb together constitute a longitudinal section through a wellapparatus, with the parts arranged for running the equipment in a wellbore, Fig. lb being a lower continuation of Fig. in;

Fig. 2 is an enlarged longitudinal section through a portion of theapparatus;

Fig. 3 is a cross-section taken along the line 3-3 on Fig. 2;

a view similar to Fig. 1b, disclosing the packer portion of theapparatus anchored in packed-eff condition within a well casing;

5 is a cross-section taken along the line 5-5 on Fig. lb;

Fig. 6 is a cross-section taken along the line G-t on Fig. l;

Fig. 7 is a section taken along the line 7-! on Fig. 5;

Fig. 8 is a fragmentary side elevation taken along the curved line 8-8on Fig. 5;

Fig. 9 is a cross-section taken along the line 9-9 on Fig. 113;

Fig. 10 is a view similar to Fig. 9 of the slip member expanded againstthe casing;

Fig. 11 is a section taken along the line ll-ll on Fig. 9;

Fig. 12 is a side elevation taken along the curved line l2l2 on Fig. 9;and

Fig. 13 is an enlarged fragmentary longitudinal section of the lowerslip guide arrangement.

In the form of the invention disclosed in the drawings, it is desired torun a well packer A to a desired location in a well casing B disposedwithin a bore hole. The packer is then anchored in packed-off conditionagainst the well casing through use of a setting tool C connected to it.This setting tool is attached to the lower end of a running-in string D,such as a wire line, extending to the top of the well bore.

The general organization of setting tool C and well packer A isdescribed and claimed in my application for Apparatus for OperatingTools in Well Bores, Serial No. 80,851, filed March 11, 1349, now PatentNo. 2,640,546.

The packer A includes a tubular body it having a body abutment llthreaded on its lower end, and an enlarged head l2 at its upper end,along which the skirt 13 of a cylinder M is slidably mounted. A cylinderhead [5 extends inwardly from the lower end of the skirt and slide.- blyengages the external cylindrical surface of the body It. Body ports isprovide communication between the interior of the body and the cylinder14, leakage between the body and cylinder being prevented by the sideseal rings ll. The packer disclosed can be run on a tubing string ifdesired. and set hydraulically, which necessitates the use of the portsI 6 and seal rings ll. When the present setting tool C is used, however,the ports [6 and rings l'l may be omitted, although such omission is notessential.

A set of upper segmented slips N3 is disposed around the body Itimmediately below the cylinder head 65. These slips are held initiallyin retracted position by shear screws i9, attaching them to an upperconical expander 28 initially se cured to the body by one or more shearscrews 2 I. The converging surfaces of the upper set of slips :8 andupper expander 29 are so disposed with respect to one another as tosecure the packer A against movement in an upward direction within thecasing B, following outward expansion of the slips l8 into engagementwith the casing.

A set of lower segmental slips 22 is provided adjacent the body abutmentII, and these slips are also secured by shear screws 23 to a lowertapered expander 24 attached initially to the body ill by one or moreshear screws 25. The direction of taper on the exterior of the lowerexpander 24 and the taper on the cooperable surfaces of the lower slips22 are such as to hold the well packer A against movement in a downwarddirection, following expansion of the slips 22 outwardly against thecasing B.

A suitable lock is provided between the body i and the upper expander 20to permit upward movement of the body [0 within this expander, but topreclude its downward movement. Such lock may be of any suitable form.It is illustrated as including a split ring 26 received within a groove21 in the upper expander and engageable with the downwardly facingratchet teeth 23 on the body.

A suitable packing 29, such as a packing sleeve, of rubber or similarpliant, elastic material, is disposed around the body l0 between theupper and lower expanders 20, 24. The ends of the packing sleeve arereceived within annular pockets formed between the expander skirts 30and the exterior of the body.

In setting the packer A, a downward force is exerted on the cylindersleeve M of sufficient extent to shear the screws 19 attaching the upperslips 18 to the upper expander 20. These slips are then moved downwardlyalong the upper expander and radially outward into anchoring engagementwith the well casing. Such outward expansion of the upper slips It canoccur, since their retaining shear screws l9 have a lesser combinedshear value than the shear screws 2! attaching the upper expander 20 tothe packer body l0. These last-mentioned screws have a lesser shearvalue than the screws 25, 23 holding the lower expander 26. to the bodyand the lower slips 22 to the lower expander.

After the upper slips I3 have been engaged with the well casing, anupward strain or pull is im parted to the packer body 10, which shearsthe screws 2| holding the upper expander 20 to the body, and moves thelower expander 24 and lower slips 22 with the body toward the upperexpander. This action foreshortens the packing sleeve 29 and effects itsoutward expansion into firm sealing engagement with the wall of thecasing B.

Thereafter, an increase in the upward pull or force on the packer bodyIii substantially simul taneously shears the screws 25, 23 holding thelower expander 2 to the body and the lower slips 22 to the lowerexpander, causing the lower body abutment H to shift the lower slips 22upwardly along the lower expander and radially outward into anchoringengagement with the wall of the casing. The split, contractible lockring 26 then engages the ratchet teeth 28 formed on the body to lock thelatter against downward movement, since such downward movement istransmitted through the upper expander 20, packing 29, lower expander 24and lower slips 22 to the well casing B. Upward movement of the body isresisted by the engagement of the lower abutment II with the lower slips22, the upward force being transmitted from the latter through the lowerexpander 24, packing sleeve 29, upper expander 20 and upper slips [8 tothe well casing 13 (see Fig. 4).

In the manner just described, the well packer A is anchored inpacked-oil condition against longitudinal movement in both directionswithin the wall casing B.

The well packer disclosed is designed primarily for use in producing oiland gas wells. It has a central bore or passage 3|, which can be closedby a flapper valve head 32 pivoted on the abutment II and urged by aspring 33 to closed position against a body abutment valve seat 34. Aslotted junk pusher and feeler 35 may be attached to the abutment I I toprevent premature setting of the packer during its descent in the wellcasing.

It is desired to provide an arrangement which will enable the wellpacker A to be run in the well casing B in a rapid manner. Suchexpeditious lowering of the well packer in the well casing can beaccomplished through use of a wire line D. It is desired to set thepacker fully and firmly against the casing without imposing a strain onthe wire line. A substantially large strain or pull on the packer partsmay be required, and, for this reason, the mechanism for setting thepacker must be capable of transmitting a large force and ofautomatically releasing itself from the well packer when the desiredmaximum force has been exceeded. Moreover, it is desired to set a typeof packer which is used primarily in the production of oil, gas, and thelike, and which has the un obstructed central passage 3| therethrough,in order to permit subsequent movement of production equipment into orthrough the packer.

The above purposes are effectuated with the equipment disclosed in thedrawings. As shown therein, setting of the well packer is dependent uponthe development of a gas pressure within the setting tool C securedinitially to the well packer. This gas pressure is developed within theupper portion of a cylinder 38, consisting of a generally cylindricalsleeve 3?, an upper head 32 threaded into the sleeve, and also a lowerhead 39 threaded into the sleeve.

A motivating gas under pressure is generated in the cylinder, and thisforce is imposed upon a piston 46 slidably mounted in the cylinder. Thispiston 36 has one or more ring grooves ll in its periphery for theaccommodation of seal rings 53, to prevent leakage between the piston itand cylinder sleeve 31. As disclosed, these rings 41; may consist ofrubber, round in cross-section, to guard against leakage in bothdirections.

The upper end of a piston rod 49 is threadedly connected to the piston46, the rod extending downwardly through the lower cylinder head 39 to apoint therebelow, where an anvil or crosspiece 50 is mounted within atransverse slot 5| in the rod. Leakage between the rod 49 and lowercylinder head 39 is prevented by suitable rod packing 52, in the form ofone or more round rubber or rubber-like seals, engaging the periphery ofthe rod and disposed within suitable ring grooves 53 in the head. Thepacking or seal rings 52 prevent leakage of liquids from the well casinginto the cylinder below the piston 46, insuring that air underatmospheric pressure is present below the piston 43 when the apparatusis assembled and lowered in the well casing.

It is desired to transfer the downward movement of, or force imposedupon, the piston 56 and the piston rod 49 to the upper slips it? of thepacker, and the relative upward movement of the cylinder 36 to thepacker body it, in order to obtain the desired anchoring of the packerin the well c sing, in the manner described above. To accomplish thispurpose, a tubular actuating mandrel 54 is threadedly connected to thelower cylinder head 39. The lower end of this mandrel 54 is coupled tothe packer body i0 through the agency of a frangible connecting device.As specifically disclosed, the lower end of the mandrel 54 is threadedinto an adjuster sub 54a, which is threaded onto the upper end of atension rod 55 extending downwardly within the packer body Ill. Thelower end of this rod is threaded into a tension head 55 screwed ontothe upper end of a releasing stud 5? having an intermediate portion 51of reduced diameter. The lower end of this stud is threaded into adepending shank 58, that is, in turn, secured to a latch retainingabutment as having an upward and inwardly inclined face iii). Thecylindrical portion 61 of the abutment engages the packer valve head 32,to hold it in open position.

Any upward force imposed upon the tension rod 55, tension head 5",releasing stud 5?, shank 55 and retaining abutment 59 is adapted to beimparted to the packer body Hi. This force is transferred from theinclined face 69 of the retaining abutment onto companion inclined,inner faces 52 on latch feet 63 integral with springlike leg members 5:?forming the lower portion of a latch sleeve 65, which extends upwardlyto a point along the tension head 56. At this point, the sleeve isprovided with an inturned shoulder 55 that can be spaced upwardly from alower flange or shoulder 61 on the tension head 55. The outer inclinedfaces 63 of the latch feet engage the valve seat M on the body abutmentii, and serve to transmit any upward force imposed on the retainingabutment 59 directly to the packer abutment l i, which forms part of thepacker body Hi.

When the parts forming the mechanism for coupling or looking the tensionrod 55 and tension head 55 to the packer abutment H occupy the positionshown in Figs. lb and 4, the latch sleeve shoulder 55 is disposed asubstantial distance above the tension head shoulder 61. The inclinedface 65 of the retaining abutment 59 bears upon the inclined faces 62 ofthe latch feet 63 and tends to urge and hold them out wardly against thevalve seat 34. Such outward movement may be limited by engagement of thelower portions 65 of the spring legs 84 with the inner surface iii ofthe packer abutment.

Upon the exertion of sufficient tension on the releasing stud 5? to pullit apart, the shank 5% and retaining abutment 59 may drop downwardly, asexplained in my above-identified application, to remove the abutment 59from its retaining position behind the latch feet 63, and allow thelatter to be disen aged from the packer abutment ii, The latch retainingabutment 55 and its shank 58 can drop to the extent limited by theengagement of its shoulder H with an inwardly directed flange 12 on aretrieving sleeve it threaded onto the lower end of the tension head 55.

Following disruption of the releasing stud 5? and dropping of the latchretaining abutment upward movement on the tension rod 55 will lift thetension head 56 with it, causing the shoulder 51 on the latter to engagethe upper shoulder 65 on the latch sleeve 65, pulling the latch legs 5dand their foot portions 63 upwardly and inwardly within the packer body10.. Such upward movement of the tension rod 55 and tension head 55 alsocauses the retrieving sleeve shoulder 12 to engage the shoulder H on theshank 58 and elevate the retaining abutment 55 through the packer. It isto be noted that all of the locking elements, with the exception of thespring-like foot portions 53 on the latch sleeve 65, are smaller indiameter than the internal diameter of the passage 3| through the packerbody 10. Since the spring-like feet 53 and legs 5d can flex inwardly,the entire locking mechanism may be removed from a set well packer A,and removed with the remaining portions of the setting tool C to the topof the well bore. It is also to be noted that the initial distancebetween the latch sleeve shoulder 65 and tension head shoulder 56 issubstantially less than the distance between the shank shoulder H andretrieving sleeve shoulder 12. This disparity in distance insuresagainst the abutment 59 again moving within the latch feet 63 duringelevation of the setting tool after disruption of the stud 51.

The piston rod 19 is movable downwardly within the bore '15 of theactuating mandrel 54, the cross-piece 50 projecting in oppositedirections from the rod 4a through diametrically opposed longitudinallyextending slots 15 formed through the mandrel wall. The cross-piece 5!also extends into opposed slots 71 formed through a setting ring orsleeve 18 slidably mounted on the actuating mandrel 54, to form aconnection between the piston rod and the setting ring 18. A settingsleeve or skirt 19 is adjustably threaded on the setting ring 18, thelower portion of the skirt being secured to a ring resting on top of thepacker cylinder sleeve [3.

As indicated above, a gaseous force or pressure is imposed upon thepiston 46. This force moves the piston and piston rod 49 downwardly andthe cylinder 36 in a relative upward direction. The downward movement ofthe rod 49 is transmitted to the ring through the anvil 50, setting ring78, and sleeve 19; whereas, the upward movement of the cylinder 36 istransmitted to the packer body It through the actuating mandrel 54, sub5 2a, tension rod 55, tension head 55, stud 51, shank 58, abutment 59,latch feet 63 and body abutment H. Accordingly, it is apparent that thedevelopment of suflicient pressure in the cylinder 36 acting upon thepiston is will eventually shear the screws i9 holding the upper slips i8to the expander 20, and move the slips outwardly against the casing.Thereafter, the cylinder 36 will move upwardly to move the body it) inthe same direction for the purpose of expanding the packing sleeve 25against the casing B, and the lower slips 22 against the casing, in themanner described above.

In order to obtain the desired operational sequence, a combustible fuelor power charge 8:! may be contained within the upper end of thecylinder 35. The combustion charge, such as a railway flare ofcylindrical or stick form, is placed in the upper head end 38 0f thecylinder 36 within a combustion chamber 82 formed therein. The charge isignited by a blank cartridge 83 contained within a gun barrel 84inserted within the upper end of the upper cylinder head 33. Leakagebetween the barrel and head is prcvented by suitable side seals 85 onthe barrel engaging the wall of the head.

The barrel 84 is threaded into a cable head 86, which, in turn, isthreadedly secured to the upper end of the cylinder head 38. The wireline running-in string D is suitably secured to the cable head 85, in aknown manner, and has the lower end of its electrically conductive wireor core 8i connected electrically to a heating filament 88 containedwithin the cartridge 83.

The apparatus is lowered in the well bore with the parts in the positionshown in Figs. 1a, and lb. When the depth in the casing B is reached atwhich the well packer A is to be set, the electrical circuit through thecartridge filament 88 is completed, which fires the cartridge 83. Theflame issuing therefrom ignites the upper end of the power charge 8!,initiating its combustion. This charge contains its own source of oxygento support combustion. As combustion proceeds, a gaseous pressure isdeveloped within the cylinder 35 above the piston 45. As the pressureincreases, the piston 46 is urged downwardly and the cylinder 36relatively upwardly. The force imposed on the piston is transmittedthrough the rod 49, cross-piece 50, and setting ring 13 to the sleeve'19, ring 89 and cylinder Hi, which bears against the upper slips [8.Downward movement of the lower piston 46 takes place against therelatively slight resistance of the air in the cylinder 36 below thepiston 45, which is initially at atmospheric pressure, and also againstthe hydrostatic head of fluid in the well casing acting upa wardlyacross the cross-sectional area of the piston rod 49. When sufficientpressure has been developed within the cylinder 36 by the gaseousmedium, and has been transmitted to the slips it, to overcome the shearstrength of the shear screws 19, and also the hydrostatic head of fluidacting upwardly on the piston rod 49, the slips it are released from theexpander 20 and are pushed downwardly along the latter into outwardengagement with the casing B.

As the combustible charge 8| continues to burn, the gas pressure withinthe cylinder 35 increases to a further extent, and this increasedpressure or force is transmitted to the lower piston Q5. Since the upperslips is are wedged against the casing, the piston I16 cannot movedownwardly to any further appreciable extent. Instead, the cylinder 36,actuating mandrel 54, sub 54a, tension rod 55, tension head 56, stud 51,shank 53, latch retaining abutment 59, latch feet 63, abutment i I andits packer body W are urged in an upward direction. When the pressureand force within the cylinder 36 has increased sufiiciently to overcomethe shear strength of the screws 2| holding the upper expander 28 to thebody it), such screws are disrupted and the packer body is movedupwardly within the upper expander 28 to compress the rubber packersleeve 23 between the upper and lower expanders 20, 24, forcing it intofirm sealing engagement with the casing wall.

Further increase in the cylinder gas pressure, as a result of thecontinued combustion of the charge 8!, effects shearing of the screws25, 23

attaching the lower expander 24 to the body It a and the lower slips 22to the lower expander, allowing the cylinder 36 to move upwardly andcarry the body it and lower slips 22 in an upward direction to shift thelatter radially outward into engagement with the casing.

The pressure in the cylinder 36 continues to increase, as combustion ofthe charge 81 proceeds, and all of the packer elements are engaged morefirmly with the casing B. When the pressure exceeds the tensile strengthof the reduced diameter portion 51a of the releasing stud '1 securingthe actuating mandrel 5A indirectly to the body l0, this stud 57 ispulled apart at its reduced diameter portion 51a to releaseautomatically the setting tool C from the well packer.

As indicated above, such release of the setting tool occurs as a resultof dropping of the latch retaining abutment 59 and the shank 5S totheextent limited by engagement of the shank shoulder H with theflange 12of the retrieving sleeve 13. This dropping removes the latch retainingabutment 59 from its holding position behind the latch feet 63 andallows the latter to be pulled upwardly with the remainder of thesetting tool C during elevation of the latter. This upward pullingoccurs because of engagement of the tension rod shoulder 61 with theinturned shoulder 88 on the latch sleeve 65. Of course, the shank 58 andlatch retaining abutment 59, as well as the lower broken portion of thereleasing stud 51, are also elevated through the well packer A with theremainder of the setting tool, since these elements are supported by theretrieving sleeve flange '52.

Accordingly, it is apparent that all of the setting tool mechanism C isreleased irom the set and anchored well packer A, and the entiremechanism elevated by means of the wire line D to the top of the wellbore.

After the setting tool has been removed from the well casing, productionequipment (not shown) may then be run in the well casing for suitablecoaction with the well packer A in producing the well from one or morezones below the well packer. The central passage 3| through the packerbody ID is unobstructed, except for the lower back pressure valve head32, which is readily displaced to one side, allowing the productiontubing and other equipment to be placed in leakproof engagement with thepacker body [0 and also allowing such equipment to extend completelythrough the packer body, if desired, to a point therebelow.

During lowering of the setting tool 0 and well packer A organization inthe well bore by means of the wire line D, there may be a tendency forrelative rotation to occur between the well packer and the setting tool,or between parts of the setting tool itself. As an example, relativerotation may occur between the tension rod 55 and the adjuster sub 54aattached to the lower end of the setting mandrel 54. The threadedconnection between the tension rod 55 and adjuster sub 54a is preferablya right-hand one.

; If relative rotation between the adjuster sub and tension rod is insuch a direction as to screw the rod 55 further into the sub, nothingdetrimental to the equipment can occur. However, if the direction ofrotation is such as to unthread the tension rod 55 from the adjuster sub54a, and if such unthreading or unscrewing is sufficient in extent, theresult may be a complete disconnection between the tension rod and theadjuster sub, which has the elfect of disconnecting or detaching allparts of the setting tool above the tension rod 55 from the couplingportion of the setting tool within the packer A, and of eiTectivelydisconnecting the setting tool C from the well packer.

Were the foregoing undesirable action to oc-- cur, the well packer Awould drop down the easing B and would be lost in the hole.

In order to guard against such undesired re lease of the major portionof the setting tool from the tension rod 55, a locking device isprovided between the tension rod and the adjuster sub. This lockingdevice does not interfere with the threading of the tension rod 55upwardly into the sub 54a, but it does prevent rotation of the tensionrod with respect to the sub in the opposite direction.

The locking device illustrated in the drawings consists of a helicalleft-hand spring 9E: having its lower end 9! fitting within an endgroove slot 92 in the upper end'of the tension rod 55. This spring iswound left-hand or opposite to the right-hand threads on the tension rodand adjuster sub. The peripheral portions of the spring turns snugly andfrictionally engage the inner cylindrical wall 93 of the adjuster sub54a.

In the event that the tension rod 55 is threaded upwardly into theadjuster sub, such action is not resisted one bit by the lock spring 90,since such right-hand turning of the tension rod twists the spring inthe proper direction, to release its periphery from frictionalengagement with the wall 93 of the adjuster sub. However, should thetension rod 55 tend to turn in the opposite or lefthand direction, suchaction would tend to expand the lock spring 55 and urge it more firmlyagainst the wall of the adjuster sub. Thus, the lock spring 95 functionsin the nature of a one-way brake, preventing unscrewing of the tensionrod 55 in a downward direction from the adjuster sub 5541, but readilypermitting its upward threading into the adjuster sub. Accordingly, thelock sprnig 59 prevents relative rotation between the adjuster sub andthe tension rod in a direction which would cause the latter to unthreadfrom the adjuster sub 55a, and allow the well packer A and the loweradapter portion of the setting tool C to drop off the setting mechanism,and be lost in the well bore.

The lock spring 95 is readily inserted in the adjuster sub duringassembly of the apparatus, before the tension rod 55 is threaded intothe sub. The lock spring need merely be twisted in the proper direction,as to the right, and forced into the sub bore through its upper enduntil it engages the bottom of the smooth portion 93 of the bore. Thetension rod 55 is then threaded into the adjuster sub 55a, its slot 92receiving the lower end 9! of the lock spring. Thereafter, upwardthreading of the tension rod can continue, the lock spring merelyretracting or releasing itself from the wall 53 of the adjuster sub.Thus, the lock spring does not interfere or offer any materialresistance to threading of the tension rod into the adjuster sub to thedesired extent. It does, however, as described above, preventunthreading of the tension rod from the adjuster sub.

When the parts are to be dismantled, the lock spring 55 would preventunscrewing of the tension rod 55 from the adjuster sub 2a. However, thesetting mandrel 55 can be unthreaded from the adjuster sub 54a and thelatter then threaded downwardly along the tension rod 55, which actionis not interfered with by the lock spring 99, since turning of theadjuster sub to the right releases the spring from the adjuster sub wall95. The sub is turned until it is fed downwardly along the tension rodto the extent in which the lock spring 55 is positioned out of thecylindrical bore or passages 93 of the sub, whereupon the lock springmay be lifted out of connecting relation with the tension rod. With theremoval of the lock spring, the adjuster sub 5511 may then be turned inthe opposite direction to unthread it completely from the tension rod55.

As described above, the latch retaining abutment 59 is held initially inan upward position, with its inclined face 55 engaging the latch feet53, and thereby coupling the setting tool C to the well packer A. In theevent that the abutment 59 were to move downwardly, the latch feet 63would be released and the well packer might drcp downwardly to aposition in which the latch feet were retracted and the entire packerdisconnected froin the setting tool. Such action could occur, forexample, in the event that the piston 45 were not at the uppermost endof its stroke, which might allow the cylinder 36 to shift downwardly,this downward motion being transmitted through the setting mandrel 54,tension rod 55, tension head 56, release stud 51 and shank 58 to theretaining abutment 59, shifting it downwardly of the latches 63.

To preclude the aforementioned possibility, a locking plate 95 isdisposed over the tension rod 55 and engages a shoulder 95 in the packerbody it at the lower end of its threaded box 9'1. This plate is held inthis position by a suitable lock nut 83 threaded on the tension rod andengaging the plate 95, the nut having a plurality of radial pins 99extending outwardly therefrom for cooperation with a suitable tool (notshown). The lock nut 98 is tightened against the lock plate 95 to theextent necessary to hold the latch retaining abutment 59 in itsuppermost position and with its inclined face 60 securing the latch feet53 outwardly in appropriate engagement with the body valve seat 34.

With the locking plate 95 and lock nut 98 arrangement, any downwardforces imposed on the tension rod 55 cannot effect downward shifting ofthe latch retaining abutment 59, sincethe downward force is transmittedthrough the lock nut 98 and plate 95 to the packer body l0. However, thenut and plate do not interfere with the disruption of the release stud51 after the packer A has been fully set, and the consequent droppingdown and release of the latch retaining abutment 59 from the latches 63,which effectively disconnects the entire setting tool C from the wellpacker A and allows the setting tool to e withdrawn to the top of thewell bore.

The locking plate 95 and lock nut 98 arrangement also has the functionof preventing the tension mandrel 55 from rotating with respect to thepacker A, which might tend to effect disconnection of some of the otherthreaded connections therebelow, as the various threaded connections inthe tension head 56, release stud 5i, shank 58 and retaining abutment59.

The locking nut and plate arrangement also permit the lower adapterportion 55, 56, 57, 58, 59, etc. of the setting tool to be assembled ina shop or warehouse before the equipment is transported to the welllocation, all of which adds to the convenience and ease of relating thevarious parts of the apparatus to one another. The entire couplingdevice secured to the lower end of the tension rod 55, and the tensionrod itself, can be mounted in the packer A in the shop, the lockingplate 95 and lock nut 98 then being properly mounted in place, togetherwith the adjuster sub 54a and lock spring 95. At the well location, itis merely necessary to secure the setting mandrel 54 in the adjuster sub5 1a, and bring the ring attached to the lower end of the setting sleeve19 into contact with the upper end of the cylinder sleeve l3.

The well packer employs an upper and lower arrangement which insuresproper location and spacing of the slip segments when they are shiftedoutwardly into engagement with the wall of the well casing. The upperslips l8 consists of a plurality of arcuate segments Hill preferablyhaving weakenin longitudinal inner grooves lill which are in alignmentwith longitudinal peri heral outer grooves or notches 52. The alignedinner and outer grooves llll, H32 form weakened sections along whicheach segment can break when being wedged against the casing B by thetapered upper expander 20, in order that the smaller segments, intowhich the slips are broken, can conform more closely to the curvature ofthe casing wall, and thereby provide a greater anchoring force of theslips [8 in the casing.

When the slips are in a retracted position, they are located in properspaced relationship by the shear screws 19. However, once these shearscrews [9 are disrupted, the slips I3 may not retain their spacedrelation in being expanded outwardly against the casing. To insure maintenance of this relationship, each segment i'ilil is provided with aradial end guide groove IE3 in its upper portion, in which a locatin pinlo l, secured to the cylinder head I5, is slidably received. When thecylinder [4 is moved downwardly to shift the upper slips I8 along theupper expander 20, the shear screws I9 are disrupted and the guidinggrooves I03 slide along the locating pins EM, in order to hold the slipsegments [00 uniformly spaced with respect to each other, to the fullextent of their outward expansion into engagement with the well casingB. Thereafter, the exertion of an adequate wedging force between theexpander 29 and slips ill will break each segment liifi into smallersegments, as described above, with the wickers $95 of the slips firmlyembedded into the wall of the well casing, and with all of the slipsegments I00 disposed substantially uniformly around the upper expander20 and well casing B.

A similar arrangement is provided with respect to the lower slipassemblage 22, in which the lower slips also have the longitudinal innerand outer aligned peripheral weakened grooves Ulla, lli2a. These slipsalso have the end guide grooves |03a in their large or lower portionreceiving the locating pins 164a, which, in this instance, are securedto a washer or disc I86 resting upon the body abutment l 1.

During lowering of the equipment in the well bore, the lower slips 22might encounter some foreign object and become prematurely tripped orexpanded. To minimize this possibility, the shear screws 23 securing theslips to the lower expander 24 are supplemented by actually integratingeach slip segment liilla to its neighboring slip segment. As a matter offact, the lower slips 22 are at first integral with one an other, theslip assembly being formed from an integral piece of metal having theweakening and guide grooves referred to above. In addition, preferablyspaced equi-angularly apart, the slip ring or sleeve has additionalweakening internal grooves I01. This deeper groove H11, in conjunctionwith an external aligned weakenin groove 102a leaves a relatively smallmetallic bridge H18 between the adjacent segments lflfla, holding thesegments to one another, and, of course, resisting their outwardexpansion, since the slip member 22 is at first a solid ring. Assumingthat three main Slip segments lfllla are to be used, the deeperweakening grooves l9! and their aligned external peripheral grooves lBZawill be spaced 120 degrees apart.

When the packer body ID is pulled upwardly, in order to set the lowerslips 22 against the casing, the first action is to shear the lowerscrews 23. Almost simultaneously, the metallic bridges 998 between themain segment portions Hlfia of the slip sleeve are disrupted by thewedging action of the expander 24, which breaks the sleeve into threemain segments 108a, or places them in essentially the same condition asthe upper slip segments I00. Thereafter, each lower slip segment Iilflais guided outwardly, until it engages the well casing B, by the locatingand guide pins I841; extending upwardly from the washer or disc I66.When sufficient wedgin force is exerted on each slip segment lOlla, itwill break at its other weakened portions into a plurality of smallersegments.

It is unnecessary for the upper segments I80 to be initially formed as asolid integral sleeve, inasmuch as any foreign particles or substancesthat might engage the upper slips, durin lowering of the equipment inthe well casing, could not urge such slips outwardly toward the wellcasing. Instead, the tendency is for such slips to be urged andmaintained in their retracted position. This is not true of the lowerslips 22, however, since any upward force imposed upon them tends toshift them upwardly along the lower expander 24 and radially outwardagainst the well casing B.

The upper slips [8 are held in retracted position by the shear screws l9alone, which can be made to disrupt at a predetermined force withinrelatively close limits. The metallic bridges I93, however, may have agreat variation in the force required to disrupt them, but this is of no1naterial importance in connection with the lower slips 22, since theupward movement of the packer body H3 will, in any event, effect adisruption and expansion of the slips 22, and with a force which is muchless than the force required to dis rupt the release stud 51. The partsmay be so related in strength as to insure that the upper slips I8 willfirst be anchored against the well casing E, the packing sleeve 29expanded against the well casing, and the lower slips 22 then movedupwardly along the lower expander 24 and outwardly into engagement withthe well casing.

The inventor claims:

1. In well apparatus: a body; an expander on said body having acircumferentially continuous external expander surface; slip meansengageable with said expander surface for anchoring said body in a wellbore; frangible means initially securing said slip means in retractedposition with respect to said body and expander; means for relativelymoving said slip means and expander to disrupt said frangible means andshift said slip means outwardly; and means for guiding said slip meansgenerally radially during its entire outward expansion to its fullestextent.

2. In well apparatus: body means; expander means on said body meanshaving a circumferentially continuous frusto-conical external surface; adevice providing segment-a1 slips engageable with said surface of saidexpander means for anchoring said body means in a well bore; frangiblemeans initially securing said slips in retracted position;instrumentalities for relatively moving said slips and expander means todisrupt said frangible means and shift said slips outwardly; andcoengaging means on said slips and one of said means for guiding saidslips during their entire outward expansion to their fullest extent.

3. In well apparatus: a body; an expander on said body having acir-cumferentially continuous frusto-conical external surface; a deviceproviding segmental slips engageable with said expander surface foranchoring said body in a well bore; frangible means initially securingsaid slips in retracted position; instrumentalities for relativelymoving said slips and expander to disrupt said frangible means and shiftsaid slips outwardly;

and coengaging means on said slips and body for guiding said slipsduring their entire outward expansion to their fullest extent.

4. In well apparatus: a body; an expander on said body having acircumferentially continuous frusto-conical external surface; a deviceproviding segmental slips engagea'ble with said expander surface foranchoring said body in a well bore; frangible means initially securingsaid slips in retracted position; instrumentalities for relativelymoving said slips and expand-er to disrupt said frangible means andshift said slips outwardly; and pin and groove means on said body andthe end portions of said slips for guiding said slips during theirentire outward expansion to their fullest extent.

5. In well apparatus: a body; an expander on said body having acircumf-erentially continuous external expander surface; a deviceproviding segmental slips engageable with said expander sur face foranchoring said body in a well bore: frangible means initially securingsaid slips in retracted position; instrumentalities for relativelymoving said slips and expander to disrupt said frangible means and shiftsaid slips outwardly; the ends of said slips having generally radialgrooves therein; and pin means on said body in said grooves for guidingsaid slips during their entire outward expansion to their fullestextent.

6. In well apparatus: a body; an expander on said body; a slip membercooperable with said expander for anchoring said body in a well bore;said slip member being initially a solid circumferentially continuousannulus when placed in aposition cooperable with said expander andhaving longitudinally extending arcuately spaced weakened sectionstherein; additional longitudinal weakened sections between saidfirst-neutioned sections and substantially stronger than saidfirst-mentioned sections; and means for shifting said expander and slipmember with respect to each other to break said member at saidfirst-mentioned weakened sections into a plurality of segments andexpand said segments outwardly.

'7. In an anchoring device for a well tool: a solid circumferentiallycontinuous annular slip member having longitudinally extending arcuatelyspaced weakened sections therein; and additional longitudinal weakenedsections between said first-mentioned sections but substantiallystronger than said first-mentioned sections.

8. In well apparatus: a body; an expander on said body; a slip membercooperable with said expander for anchoring said body in a well bore;said slip member being initially a solid circumferentially continuousannulus and having longitudinally extending arcuately spaced weakenedsections therein; additional longitudinal weakened sections between saidfirst-mentioned sections and substantially stronger than saidfirst-mentioned sections; means for shifting said expander and slipmember with respect to each other to break said member at saidfirstmentioned weakened sections into a plurality of segments and expandsaid segments outwardly; the ends of said segments having generallyradial grooves therein; and pin means on said body extending into saidgrooves.

9. In well apparatus: a body; an upper expander on said body; uppersegmental slips cooperable with said upper expander for anchoring saidbody in a well bore again-st upward movement; a lower expander on saidbody; a lower slip member cooperable with said lower expander foranchoring said body in a well bore against downward movement; said lowerslip member being initially a solid circumferentially continuous annulusand having longitudinally extending arcuately spaced weakened sectionstherein; means for shifting said expanders, upper slips and slip memberswith respect to each other to expand said upper slips outwardly and tobreak said slip member at said weakened sections into a plurality ofsegments and expand said segments outwardly; said upper slips andsegments having generally radial end grooves therein; and pin means onsaid body disposed in said grooves to guide said upper slips and lowersegments during their outward expansion.

10. In well apparatus: a body; an expander on said body; a slip membercooperable with said expander for anchoring said body in a Well bore;said slip member having external wickers thereon; said slip member beinginitially a solid circumferentially continuous annulus and havinglongitudinally extending arcuately spaced weakened sections therein,each weakened section being provided by a longitudinally extendinginternal groove in said member and a longitudinally extending groove insaid member radially aligned with said internal groove; additionallongitudinal weakened sections between said first-mentioned sections andsubstantially stronger than said first-mentioned sections, eachadditional weakened section being provided by a longitudinally extendinginternal groove in said member of lesser radial extent than said otherinternal groove and a longitudinally extending external groove in saidmember radially aligned with said internal groove of lesser radialextent; and means for shifting said expander and slip member withrespect to each other to break said member at said first-mentionedweakened sections into a plurality of segments and expand said segmentsoutwardly.

11. In an anchoring device for a well tool: a solid circumferentiallycontinuous annular slip member having external wickers thereon andlongitudinally extending arcuately spaced weakened sections therein,each weakened section being provided by a longitudinally extendinginternal groove in said member and a longitudinally extending externalgroove in said member radially aligned with said internal groove;additional longitudinal weakened sections between said firstmentionedsections but substantially stronger than said first-mentioned sections,each additional weakened section being provided by longitudinallyextending internal grooves in said member of lesser radial extent thansaid other internal groove and a longitudinally extending externalgroove in said member radially aligned with said internal groove oflesser radial extent.

References Cited in the file of this patent UNITED STATES PATENTS NumberName Date 2,153,035 Burt Apr. 4, 1939 2,204,659 Burt June 18, 19402,368,409 Burt Jan. 30, 1945 2,399,766 Steward May '7, 1946 2,467,801Baker Apr. 19, 1949

